U.S. patent application number 12/267771 was filed with the patent office on 2009-05-14 for tagging a formation for use in wellbore related operations.
This patent application is currently assigned to BAKER HUGHES INCORPORATED. Invention is credited to Andrew D. Kirkwood, Stephen P. Monroe.
Application Number | 20090120637 12/267771 |
Document ID | / |
Family ID | 40622623 |
Filed Date | 2009-05-14 |
United States Patent
Application |
20090120637 |
Kind Code |
A1 |
Kirkwood; Andrew D. ; et
al. |
May 14, 2009 |
Tagging a Formation for Use in Wellbore Related Operations
Abstract
A system for positioning a wellbore tool in a wellbore
intersecting a subterranean formation includes a tag embedded in
the formation using a tag insertion device. The tag may be
configured to transmit a signal that includes information. A
wellbore tool may utilize a tag detection device to operatively
link with the tag. This operative link may provide an indication of
the relative position of the tag detection device or some other
information.
Inventors: |
Kirkwood; Andrew D.;
(Houston, TX) ; Monroe; Stephen P.; (Conroe,
TX) |
Correspondence
Address: |
MADAN, MOSSMAN & SRIRAM, P.C.
2603 AUGUSTA DRIVE, SUITE 700
HOUSTON
TX
77057-5662
US
|
Assignee: |
BAKER HUGHES INCORPORATED
Houston
TX
|
Family ID: |
40622623 |
Appl. No.: |
12/267771 |
Filed: |
November 10, 2008 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
60987897 |
Nov 14, 2007 |
|
|
|
Current U.S.
Class: |
166/254.2 ;
166/250.01; 166/65.1; 73/152.03 |
Current CPC
Class: |
E21B 47/13 20200501;
E21B 47/024 20130101; E21B 47/09 20130101; E21B 47/00 20130101 |
Class at
Publication: |
166/254.2 ;
166/250.01; 73/152.03; 166/65.1 |
International
Class: |
E21B 47/00 20060101
E21B047/00; E21B 47/12 20060101 E21B047/12; E21B 7/00 20060101
E21B007/00; E21B 23/00 20060101 E21B023/00 |
Claims
1. A method for positioning a wellbore tool in a wellbore
intersecting a subterranean formation, comprising: determining a
parameter of interest relating to the formation; determining a
selected location along the wellbore using the determined parameter
of interest; positioning a tag at the selected location in the
formation; detecting the tag; and positioning the wellbore tool in
the wellbore with reference to the tag.
2. The method of claim 1 further comprising: conveying a logging
tool into the wellbore to determine the parameter of interest
relating to the formation.
3. The method of claim 2 wherein the logging tool is positioned on
a drill string; and further comprising forming the wellbore using
the drill string.
4. The method of claim 3 wherein the tag is positioned at the
selected location while the drill string is being tripped out of
the wellbore.
5. The method of claim 2 wherein the logging tool is conveyed by a
non-rigid conveyance member; and further comprising logging the
formation using the logging tool.
6. The method of claim 1 further comprising: logging a section of
the formation to measure the parameter of interest relating to the
formation, and relogging the section of the wellbore to locate the
selected location.
7. The method of claim 1 wherein the positioning of the tag
includes embedding the tag in the formation.
8. The method of claim 1 further comprising detecting the tag with
a tag detection device associated with the wellbore tool.
9. The method of claim 8 wherein the tag detection device uses one
of: (i) radio waves, (ii) acoustic waves, (iii) magnetic waves, and
(iv) electromagnetic waves to detect the tag.
10. The method of claim 8 wherein the tag transmits a signal to the
tag detection device.
11. The method of claim 10 wherein the signal includes one of: (i)
a unique identifier, (ii) reservoir data, (iii) formation data,
(iv) fluid data, (v) borehole data, (vi) directional data, (vii)
wellbore equipment data, (viii) completion data, and (ix) position
data.
12. The method of claim 1 wherein the selected location is one of:
(i) an open hole section of the wellbore, (ii) a position radially
exterior of a wellbore tubular, and (iii) in a material forming the
formation.
13. A system for positioning a wellbore tool in a wellbore
intersecting a subterranean formation, comprising: a logging tool
configured to determine at least one parameter of interest relating
to the formation; a tag configured to be positioned in the
formation; a tag insertion tool configured to insert the tag into
the formation; and a conveyance device conveying the tag insertion
tool and the logging tool into the wellbore.
14. The system of claim 13 further comprising a tag detection
device configured to detect the tag.
15. The system of claim 13 wherein the tag includes one of: (i) an
RFID transponder, (ii) a radioactive material, and (iii) a
transmitter.
16. The system of claim 12 wherein the conveyance device is one of:
(i) jointed tubulars, (ii) coiled tubing, (iii) a slickline, and
(iv) a wireline.
17. A method for positioning one or more devices in a wellbore
intersecting a subterranean formation, comprising: logging a
section of the formation while traversing the wellbore in a first
direction to obtain a first set of data relating to the formation;
determining a selected location along the wellbore by processing
the first set of data; logging the section of the formation while
traversing the wellbore in a second direction opposite to the first
direction to obtain a second set of data relating to the formation;
processing the second set of data to find the selected location;
and positioning a tag at the selected location in the
formation.
18. The method of claim 17, further comprising: detecting the tag;
and positioning a wellbore tool in the wellbore with reference to
the tag.
19. The method of claim 17 wherein the positioning of the tag
includes embedding the tag in the formation.
20. The method of claim 17 wherein the tag uses one of: (i) radio
waves, (ii) acoustic waves, (iii) magnetic waves, and (iv)
electromagnetic waves to detect the tag.
Description
CROSS-REFERENCE TO RELATED APPLICATION
[0001] This application claims the benefit of U.S. Provisional
Patent Application No. 60/987,897 filed Nov. 14, 2007.
BACKGROUND OF THE DISCLOSURE
[0002] 1. Field of the Disclosure
[0003] This disclosure relates generally to devices, systems and
methods for positioning and using equipment used in connection with
the drilling, completion and/or workover of oilfield wells.
[0004] 2. Description of the Related Art
[0005] Valuable hydrocarbon deposits, such as those containing oil
and gas, are often found in subterranean formations located
thousands of feet below the surface of the Earth. To recover these
hydrocarbon deposits, boreholes or wellbores are drilled by
rotating a drill bit attached to a drilling assembly, also referred
to herein as a "bottom hole assembly" or "BHA." Such a drilling
assembly is attached to the downhole end of a tubing or drill
string made up of jointed rigid pipe or a flexible tubing coiled on
a reel ("coiled tubing"). For directional drilling, the drilling
assembly can use a steering unit to direct the drill bit along a
desired wellbore trajectory.
[0006] These drilled wellbores, which can include complex
three-dimensional trajectories, intersect various formations of
interest. During drilling and in later completion activities,
success or failure of effectively producing hydrocarbons from a
given formation can hinge on precisely measuring the depth of a
given formation and precisely positioning a wellbore tool at a
depth corresponding to a given formation. In some instances, a
hydrocarbon bearing zone can be only a meter or so in depth. Thus,
the positioning of wellbore tools such as a perforating gun or a
kickoff for a lateral bore must be positioned well within that one
meter range.
[0007] Conventional depth measurement systems utilize surface-based
equipment and techniques for determining a measured depth of a
downhole tool, such as a bottomhole assembly. Conveyance devices,
such as drill pipe or wirelines, that used to convey downhole
tooling are susceptible to stretching during deployment. Because
these conveyance devices can span hundreds of meters or more, the
elongation of the conveyance device may significantly impact
surface depth measurements. That is, for instance, a surface
measurement may indicate that a downhole tool is at 800 meters,
whereas, due to factors such as tensile loading, the tool is
actually at 840 meters. Thus, surface measurements may not provide
the accuracy needed to position wellbore equipment within a narrow
zone of interest, e.g., within a tolerance of a half-meter. The
present disclosure is directed to methods and devices for
accurately positioning wellbore tooling as well as methods and
devices for enhancing wellbore operations.
SUMMARY OF THE DISCLOSURE
[0008] In aspects, the present disclosure provides a method for
positioning a wellbore tool in a wellbore intersecting a
subterranean formation. In one embodiment, the method may include
positioning a tag at a selected location in the formation, and
positioning the wellbore tool in the wellbore with reference to the
tag. In aspects, another method for positioning a wellbore tool in
a wellbore intersecting a subterranean formation include
determining a parameter of interest relating to the formation;
determining a selected location along the wellbore using the
determined parameter of interest; positioning a tag at the selected
location in the formation; detecting the tag; and positioning the
wellbore tool in the wellbore with reference to the tag. The method
may further include logging a section of the formation to measure
the parameter of interest relating to the formation, and re-logging
the section of the wellbore to locate the selected location. In
aspects, still another method for positioning one or more devices
in a wellbore intersecting a subterranean formation may include
logging a section of the formation while traversing the wellbore in
a first direction to obtain a first set of data relating to the
formation; determining a selected location along the wellbore by
processing the first set of data; logging the section of the
formation while traversing the wellbore in a second direction
opposite to the first direction to obtain a second set of data
relating to the formation; processing the second set of data to
find the selected location; and positioning a tag at the selected
location in the formation.
[0009] In aspects, the present disclosure provides a system for
positioning a wellbore tool in a wellbore intersecting a
subterranean formation. The system may include a tag positioned in
the formation; a tag detection device operatively linking to the
tag; and a conveyance device conveying the tag detection device
into the wellbore. An illustrative system may include a logging
tool configured to determine at least one parameter of interest
relating to the formation; a tag configured to be positioned in the
formation; a tag insertion tool configured to insert the tag into
the formation; and a conveyance device conveying the tag insertion
tool and the logging tool into the wellbore. In aspects, another
illustrative system may include a tag configured to be embedded in
the subterranean formation to operate as the reference object; and
an injector configured to embed the tag into the subterranean
formation.
[0010] It should be understood that examples of the more important
features of the disclosure have been summarized rather broadly in
order that the detailed description thereof that follows may be
better understood, and in order that the contributions to the art
may be appreciated. There are, of course, additional features of
the disclosure that will be described hereinafter and which will
form the subject of the claims appended hereto.
BRIEF DESCRIPTION OF THE DRAWINGS
[0011] For detailed understanding of the present disclosure,
references should be made to the following detailed description of
the preferred embodiment, taken in conjunction with the
accompanying drawings, in which like elements have been given like
numerals and wherein:
[0012] FIG. 1A schematically illustrates a reference tag according
to one embodiment of the present disclosure that is embedded in a
subterranean formation; and
[0013] FIG. 1B schematically illustrates a reference tag according
to one embodiment of the present disclosure that is embedded in a
subterranean formation and positioned radially external of a
wellbore tubular;
[0014] FIG. 2 functionally illustrates a tag according to one
embodiment of the present disclosure;
[0015] FIGS. 3A and 3B schematically illustrate tag insertion tools
made according to one embodiment of the present disclosure;
[0016] FIG. 4 shows a schematic view of a drilling system according
to one embodiment of the present disclosure; and
[0017] FIG. 5 shows a schematic view of wireline system according
to one embodiment of the present disclosure.
DETAILED DESCRIPTION OF THE DISCLOSURE
[0018] The present disclosure, in one aspect relates to devices and
methods for positioning wellbore tools and/or obtaining subsurface
measured data. The present disclosure is susceptible to embodiments
of different forms. There are shown in the drawings, and herein
will be described in detail, specific embodiments of the present
disclosure with the understanding that the present disclosure is to
be considered an exemplification of the principles of the
disclosure, and is not intended to limit the disclosure to that
illustrated and described herein. Further, while embodiments may be
described has having one or more features or a combination of two
or more features, such a feature or a combination of features
should not be construed as essential unless expressly stated as
essential.
[0019] Referring initially to FIG. 1A, there is shown a wellbore 10
intersecting a formation 12. In embodiments, one or more tags 100
are positioned along the wellbore 10 at selected locations in the
rock and earth of the formation 12. The tags 100 operate as a
reference object or device that may assist in determining the
orientation and/or position of one or more tools subsequently
deployed in the wellbore 10. An illustrative tool, which has been
labeled with numeral 200, may be any tool used during any stage of
the life of a well, including drilling, completion, work-over and
production. In embodiments, the tool 200 may include a tag
detection device 202 that operatively links to the tags 100. This
operative link may be as simple as a detection of the tag 100 or as
complex as a bi-direction data communication with and power
transfer to the tag 100. Establishing this operative link provides
an indication that the tool 200 has reached a previously identified
location in the wellbore, provides information that may be useful
in operating the tool 200, and/or facilitates a desired wellbore
operation. The data and information may be transmitted to the
surface and/or used downhole.
[0020] The tag 100 may be used to orient and/or position the
wellbore tool 200 with reference to a location parameter such as
measured depth, true vertical depth, borehole highside, azimuth,
etc. The orientation and/or position may also be with reference to
a subsurface feature such as a production zone 14, a water zone 16,
a particular point or region of interest in the formation 12, as
well as features such a bed boundaries, fluid contacts between
fluids such as water and oil, unstable zones, etc. Referring now to
FIG. 1B, the tag 100 may also be used in connection with
constructed features such as a perforated zone 20 or other features
as kick-off points (not shown) for branch wells, locations of liner
hangers (not shown), packers (not shown) etc. The tag 100 may be
used in an open hole as shown in FIG. 1A or radially external to
wellbore equipment such as tubular 22, which may be a liner or
casing.
[0021] In one mode of operation, the tool 200 uses the tag
detection device 202 to detect, communicate, or in some manner
operatively link with the tag 100. Upon establishing this operative
link with the tag 100, surface personnel can then determine the
position of the tool 200 relative to the feature of interest. The
tool 200 may be operated to locate the tag 100, which then enables
positioning of the tool 200 relative to the tag 100.
[0022] While the tag 100 may operate in some embodiments as a
substantially stationary reference object that may be used to
position wellbore tools, the tag 100 may also be configured to
receive, collect, store and transmit information. The configuration
of the tag 100, therefore, may be adjusted as needed to meet a
particular function. Referring now to FIG. 2, there is shown in
functional format one embodiment of a tag 100. It is emphasized
that the features shown in FIG. 2 may be optional and as such are
not essential.
[0023] In one arrangement, the tag 100 emits an identifiable signal
102. The characteristics of the signal 102, such as amplitude or
frequency, may be sufficient for the tool 200 to identify or locate
the tag 100. The signal 102, in certain embodiments, may also
contain information that includes, but is not limited to, a unique
identification value for that tag 100. In certain embodiments, the
signal 102 may include data such as reservoir data such as
pressure, temperature, flow rates; formation data such as
resistivity, density, porosity; fluid data such as fluid
composition, borehole data such as highside, borehole diameter;
directional data such as inclination, azimuth, etc. The data may be
measurements made by in situ sensors or by tools that have
previously run in the wellbore 10. In certain embodiments, the
signal 102 may include position data such as a distance to one or
more features of interest described previously. The signals may be
digital, analog, encoded pulses or any other information-bearing
transmission.
[0024] The constituent components of the tag 100 may depend on the
particular application involved, the nature the signal 102 and/or
the degree of information that is to be conveyed by the signal 102.
For instance, the tag 100 may utilize a transmitter 110 that
transmits a signal having a predetermined characteristic such as
amplitude or frequency that enables identification of the tag 100.
To add information to the signal 102, a memory 112 may be utilized
to store data. The data may be written to the memory 112 by an
external device (not shown) or by a resident data writer 114. In
some embodiments, the tag 100 may operate continuously or
periodically. In some embodiments, a receiver 116 may be used to
receive command signals or data signals transmitted to the tag 100.
For instance, the tag 100 may assume a "sleep" or "dormant" mode
until a command signal is received by the receiver 116. Upon
receiving the command signal, the transmitter 110 may transmit the
signal 102. The receiver 116 may also be used to receive data that
is thereafter written to the memory 112 by the writer 114. In
embodiments, a sensor 118 may be used to measure one or more
desired parameters of interest and a processor 120 may be used to
process the measured data or any other received data. The
processing may include, but is not limited to, digitizing,
decimating, filtering, etc. The transmitter 100 may include an
onboard power supply 122, which may be rechargeable. The
transmitter 100 may also be energized by using as an induction
device on a tool or by a suitable power conductor to a remote power
supply in the wellbore or at the surface.
[0025] In one arrangement, the tag 100 may use radio frequency
identification (RFID) principles to establish an operative link
with the tool 200. In such an arrangement, the tag 100 may include
a transponder 124 and the tag detection device 202 of the tool 200
may include an interrogator or transceiver 204. The transponder 124
transmits the signal 102 in response to an interrogating signal 126
transmitted by the transceiver 204. The transponder 124 can be
passive or active. In one variant of the passive transponder 124,
an incoming radio frequency signal or interrogating signal 126
generates sufficient electrical current induced in an antenna (not
shown) provided in the transponder 124 for circuitry such as a CMOS
integrated circuit in the transponder 124 to power up and transmit
the responsive signal 102. As noted previously, the responsive
signal 102 can include a preprogrammed value such as an ID number
as well as collected data. In one variant of the active transponder
124, the internal power source 122 supplies power for the onboard
circuitry. The active transponder 124 can transmit such signals in
response to a signal or transmit the signals without a prompt at a
specified time, event or interval.
[0026] It is emphasized that RFID devices are merely illustrative
of devices that be used to establish communication between the tag
100 and the tag detection device 202. In other embodiments,
operative links between the tag 100 and the tag detection device
202 may be based on acoustic signals, magnetic signals, optical
signals, pressure pulses or other energy waves that may be emitted
or modulated in a controlled manner. For example, the tag 100 may
be partially or completed formed of an energy emitting material
such as a radioactive material or a magnetic material. The energy
emitting materials may be encapsulated in a shell or sheathing that
is substantially transparent to the emitted energy. The
encapsulation may be useful to protect the energy emitting material
for the corrosive wellbore environment and help prevent the energy
emitting material from migrating or dispersing. The tag detection
device 202 may be equipped with a device to detect the energy
emitted by the tag 100, such as a radiation detector or
magnetometer.
[0027] The tag 100 may be embedded into the formation using any
number of devices, two of which are shown in FIGS. 3A and 3B. FIG.
3A illustrates an insertion tool 300 that plants the tag 100 in a
controlled manner into the formation. The insertion tool 300
includes an injection module 302 and one or more decentralizing
arms 304. The injection module 302 may include an injector 306, a
control unit or controller 308 and a power supply 310. The
injection module 302 may be configured to use electrical power,
hydraulic power and/or pneumatic power. In one arrangement, the
injector 306 may be a piston or ram device that is actuated by
pressurized fluid, such as oil or gas. For example, the tag 100 may
be fixed to a member such as a pad or a rod (not shown) that is
driven against or into the formation. In other embodiments, the tag
100 may be inserted into the formation by being loaded into a
member such as a tube that is operatively coupled to a charge
device that provides a propelling force using hydraulics,
pneumatics or pyrotechnics. In other embodiments, the injection
module 302 may utilize an expandable bladder that is expanded into
engagement with a wellbore wall. In still other arrangements, an
electric motor can rotate an appropriately threaded shaft to drive
a tag 100 into the formation. In still other embodiments, the
injector 306 may use a coring bit arrangement to form a cavity in
the formation. The tag 100 may then be deposited into that cavity.
To radially displace the injection module 302, the injection module
302 includes the upper and lower decentralizing arms 304. Each arm
304 may be operated by an associated hydraulic system (not shown).
Further details regarding coring devices and decentralizing arms
are disclosed in U.S. Pat. Nos. 5,411,106 and 6,157,893, which are
hereby incorporated by reference for all purposes. The injection
module 302 may be mounted on a non-rotating sleeve that remains
substantially stationary relative to the wellbore wall while a
drill string to which the non-rotating sleeve is coupled rotates.
Thus, the injection module 302 physically engages or contacts a
wall of the wellbore and forcibly embeds one or more tags 100 into
the formation.
[0028] In the FIG. 3B embodiment, an injection module 330 propels a
tag 100 into the formation. The tag 100 may be propelled or ejected
out of the injection module 330 using a propelling force such as
pressurized gas or fluid. A pyrotechnic charge in a gun-type
arrangement may also be used to "shoot" the tag 100 into the
formation. Such an arrangement may be useful for tags that use
energy emitting materials such as radioactive materials or magnetic
materials. Such an arrangement may also be useful in applications
where the injection module 330 is traversing the wellbore. Because
the injection module 330 does not physically contact the wall of
the wellbore, the tag 100 may be ejected into the formation while
the injection module 330 is moving.
[0029] The tag or tags 100 may be embedded into the formation at
any time during the well construction or during the production life
of a well. Illustrative methods for deploying the tags are
discussed below.
[0030] Referring to FIG. 4, there is shown a drill rig 30
positioned over a formation of interest 12. As shown, a wellbore 10
is being drilled into the earth under control of known surface
equipment using a drill string 32. The drill string 32 is formed of
jointed tubulars and can include a bottomhole assembly (BHA) 40
having a drill bit 42 at a distal end. A tag insertion tool, such
as that shown in FIG. 3A or 3B, may be positioned along the BHA 40.
Merely for ease of explanation, the tag insertion tool 300 is
shown. Also shown is the tag detection device 202. While a drill
string of jointed tubulars is shown, the string can also include
coiled tubing, casing joints, liner joints or other equipment used
in well completion activities. Additionally, while a land rig is
shown, it should be understood that the teachings of the present
disclosure can be readily applied to offshore drilling such as that
performed on facilities such as drill ships or offshore platforms.
A depth measurement system 44 may be provided to generally
determine the "measured" or "absolute" depth of the BHA 40.
[0031] In one embodiment, the BHA 40 includes
logging-while-drilling tools or formation evaluation tools 50
adapted to measure one or more parameters of interest relating to
the formation or wellbore. The formation evaluation tools 50 may be
positioned downhole of the insertion tool 300 as shown or
positioned uphole of the insertion tool 300. It should be
understood that the term formation evaluation tool encompasses
measurement devices, sensors, and other like devices that, actively
or passively, collect data about the various characteristics of the
formation, directional sensors for providing information about the
tool orientation and direction of movement, formation testing
sensors for providing information about the characteristics of the
reservoir fluid and for evaluating the reservoir conditions. The
formation evaluation sensors may include resistivity sensors for
determining the formation resistivity, dielectric constant and the
presence or absence of hydrocarbons, acoustic sensors for
determining the acoustic porosity of the formation and the bed
boundary in formation, nuclear sensors for determining the
formation density, nuclear porosity and certain rock
characteristics, nuclear magnetic resonance sensors for determining
the porosity and other petrophysical characteristics of the
formation. The direction and position sensors preferably include a
combination of one or more accelerometers and one or more
gyroscopes or magnetometers. The accelerometers preferably provide
measurements along three axes. The formation testing sensors
collect formation fluid samples and determine the properties of the
formation fluid, which include physical properties and chemical
properties. Sampling tools for collecting samples can include
device utilizing probes and/or coring devices. Pressure
measurements of the formation provide information about the
reservoir characteristics.
[0032] In one mode of operation, the BHA 40 drills the wellbore
while the trailing formation evaluation tools 50 "log" the well by
measuring various parameters of interest that have been previously
described. Analysis of the logged measurements, which may be
performed downhole and/or at the surface, may reveal a feature of
interest to be tagged for future reference. The insertion tool 300
may then be operated to insert a tag 100 into the formation. The
tag 100 does not necessarily have to be positioned at the feature
of interest because the insertion tool 300 has a known fix axial
distance from the formation evaluation tools 50. Prior to
insertion, the tag 100 may be encoded with data such as the
distance to the feature of interest and other data previously
described with reference to the signal 102 shown in FIG. 1.
[0033] A variety of techniques may be employed for inserting the
tag 100. One method includes injecting the tag 100 "on the fly" as
the drill string 32 is moving. Another method includes stopping
drilling to embed the tag 100. Still another method includes
relogging the well as the drill string 32 is being tripped out of
the wellbore 10 to locate the previously identified feature(s) of
interest and then inserting the tag 100. In a similar manner, the
identification of feature(s) of interest may also be performed as
the drill string 32 is being tripped back into the wellbore 10. It
should be appreciated that each of these methods provides different
time intervals between the initial logging of the well and the
subsequent insertion of the tag 100. For example, inserting the tag
100 during a tripping out of the well or subsequent tripping into
the wellbore allows surface personnel more time to analyze the
logging data to identify feature(s) of interest suitable for
tagging.
[0034] The tags 100 may also be deployed outside of the drilling
context using tools conveyed into the wellbore 10 by a non-rigid
conveyance devices such as a wireline or slick line. Referring now
to FIG. 5, there is schematically represented a cross-section of
the formation 12 in which is drilled the wellbore 10. Suspended
within the wellbore 10 at the bottom end of a non-rigid conveyance
member such as a slick line or a wireline 52 are formation
evaluation tools 50. Positioned adjacent to the formation
evaluation tools 50 is the insertion tool 300. Also shown is the
tag detection device 202. The wireline 52 is often carried over a
pulley 54 supported by a derrick 56. Wireline deployment and
retrieval is performed by a powered which carried by a service
truck 58, for example. A control panel 60 interconnected to the
tool 100 through the wireline 52 by conventional means controls
transmission of electrical power, data/command signals, and also
provides control over operation of the components in the formation
sampling tool 100.
[0035] In one mode of operation, the formation evaluation tools 50
"log" the while being tripped into or out of the wellbore 10.
Analysis of the logged measurements, which may be performed
downhole and/or at the surface, may reveal a feature of interest to
be tagged for future reference. Using methods previously discussed,
the insertion tool 300 may be operated to insert a tag 100 into the
formation. Prior to insertion, the tag 100 may be encoded with data
such as the distance to the feature of interest and other data
previously described with reference to the signal 102 shown in FIG.
2.
[0036] With respect to FIGS. 1A, 1B, 4 and 5, it should be
appreciated that the tagging of features of interest in the
wellbore can enhance the effectiveness of subsequent wellbore
operations. For instance, the depth, orientation and position of
the BHA 40 may be more precisely determined by reference to the
tags 100 previously positioned in the wellbore. That is, as the
drill string 3 is being tripped into the wellbore 10, the tag
detection device 202 may be operated to locate the tag 100 that has
been positioned at the desired location. Such a tag 100 may emit a
signal 102 (FIG. 2) having a unique identification value. Thus, for
example, rather than relying on measured depth at the surface to
identify a kick-off point for a branch wellbore, the tags 100 may
be utilized to position a whipstock (not shown) or other diverting
device at the appropriate location in the wellbore.
[0037] In the completions and production context, the tags 100 may
be used to identify the location of features of interest to well
owners and operator such as potential pay zones, depleted zones,
unstable zones, "thief" zones (e.g., zones having relatively low
pore pressures), etc. Each of these features may be tagged with a
tag 100 transmitting a unique identification signal. Thus, the tags
100 may function as in situ references for such features during the
life of the well. Because subsequent operations in the wellbore 10
may utilize these tags 100, surface personnel may more precise
position perforating tools, screens, gravel packs, zone isolation
equipment such as packers, production tubing, artificial lift
pumps, etc.
[0038] With conventional systems, surface measured depth for
positioning such devices in relatively deep wells, say five
thousand meters, may have an error of seventy to one hundred
meters. Such an error can lead to less than optimal positioning of
completion tools. However, use of the tags 100 may substantially
reduce the error substantially because the distances involved with
positioning tooling with respect to the tags 100 may be in the
order of, say, twenty to forty meters, which, of course, would
involve a correspondingly smaller error in measured distance. It
should be appreciated that the tags 100 may be used solely or in
conjunction with surface depth measurement systems for accurate
placement wellbore tools.
[0039] During the life of a well, in addition to providing a useful
reference point for positioning tools in the well, the tags 100 may
be used to characterize the changes in a formation or reservoir
over time. For instance, downhole measurements, such as nuclear
measurements, resistivity, or acoustics, may be used to locate and
gas-oil and or oil-water contacts. The formation tags 100 may then
be used to identify such contacts and may be used to monitor shifts
or movement of such contacts over time.
[0040] In some variants, the information that may be contained in
the signal 102 (FIG. 2) is embedded directly onto a wellbore by a
method such as etching or scoring. In such variants, the injection
module is configured to cut or engrave information bearing markings
onto the wall of a wellbore. These markings may then be detected by
a reader that contacts the wall of the wellbore.
[0041] From the above, it should be appreciated that what has been
described includes, in part, a method for positioning a wellbore
tool in a wellbore intersecting a subterranean formation. In one
embodiment, the method may include positioning a tag at a selected
location in the formation, and positioning the wellbore tool in the
wellbore with reference to the tag. The selected location may at an
open hole section of the wellbore, a position radially exterior of
a wellbore tubular, or in a material forming the formation. In
variants, the method may also include determining a parameter of
interest relating to the formation, and determining the selected
location using the determined parameter of interest. The parameter
of interest may be measured using a logging tool positioned on a
drill string and the method may include forming the wellbore using
the drill string. The tag may be positioned at the selected
location while the drill string is drilling the wellbore, while the
drill string is being tripped into the wellbore, or while the drill
string is being tripped out of the wellbore. In other variants, the
parameter of interest may be measured using a logging tool conveyed
by a non-rigid conveyance member; and the method may include
logging the wellbore using the logging tool. The method may include
logging a section of the wellbore to measure a parameter of
interest relating to the formation, analyzing the measurements to
determine the selected location, and relogging the section of the
wellbore to locate the selected location.
[0042] Illustrative variants of the method may include embedding
the tag in the formation and detecting the tag with a tag detection
device associated with the wellbore tool. Still another method may
include detecting a tag embedded in the formation; and positioning
the wellbore tool in the wellbore with reference to the tag. Other
variants of methods may include positioning a wellbore tool in a
wellbore intersecting a subterranean formation that includes
determining a parameter of interest relating to the formation;
determining a selected location along the wellbore using the
determined parameter of interest; positioning a tag at the selected
location in the formation; detecting the tag; and positioning the
wellbore tool in the wellbore with reference to the tag. The method
may further include logging a section of the formation to measure
the parameter of interest relating to the formation, and relogging
the section of the wellbore to locate the selected location.
[0043] Illustrative methods may also include logging a section of
the formation while traversing the wellbore in a first direction to
obtain a first set of data relating to the formation; determining a
selected location along the wellbore by processing the first set of
data; logging the section of the formation while traversing the
wellbore in a second direction opposite to the first direction to
obtain a second set of data relating to the formation; processing
the second set of data to find the selected location; and
positioning a tag at the selected location in the formation.
[0044] From the above, it should be appreciated that what has been
described includes, in part, a system for positioning a wellbore
tool in a wellbore intersecting a subterranean formation. The
system may include a tag positioned in the formation; a tag
detection device operatively linking to the tag; and a conveyance
device conveying the tag detection device into the wellbore. The
tag detection device may use radio waves, acoustic waves, magnetic
waves, and/or electromagnetic waves to operatively link with the
tag. The tag may include an RFID transponder, a radioactive
material, and/or a transmitter. The conveyance device include
jointed tubulars, coiled tubing, a slickline, and/or a
wireline.
[0045] An illustrative system may include a logging tool configured
to determine at least one parameter of interest relating to the
formation; a tag configured to be positioned in the formation; a
tag insertion tool configured to insert the tag into the formation;
and a conveyance device conveying the tag insertion tool and the
logging tool into the wellbore.
[0046] In variants, the system may include a tag configured to be
embedded in the subterranean formation to operate as the reference
object; and an injector configured to embed the tag into the
subterranean formation. The system may further include a sensor
positioned adjacent the injector and configured to measure a
selected parameter of interest relative to the subterranean
formation. In one arrangement, the system may use a drill string to
convey the injector into the wellbore. In arrangements, the system
may include a non-rigid conveyance member conveying the injector
into the wellbore.
[0047] The foregoing description is directed to particular
embodiments of the present disclosure for the purpose of
illustration and explanation. It will be apparent, however, to one
skilled in the art that many modifications and changes to the
embodiment set forth above are possible without departing from the
scope of the disclosure. It is intended that the following claims
be interpreted to embrace all such modifications and changes.
* * * * *